What does the Alta Wind decision mean for clean energy developers and investors?

On July 8, the Court of Federal Claims issued a ruling in the Alta Wind v. United States case, providing a roadmap for how eligible basis disputes may be resolved. While the case runs on the old Section 1603 cash grant program, which allowed eligible clean energy developers to receive a direct payment from the US Department of the Treasury instead of claiming a tax credit, the court's method for separating asset cost from tax credit value will inform how the Internal Revenue Service (IRS) and courts size up basis claims under the Section 48 and 48E investment tax credit (ITC) today. However, the court suggested its circularity concern applies most directly to cash grants, and tax credits may be treated differently.

Key takeaways

• The core question in the case centers on what counts as cost for the purposes of evaluating the basis of an eligible property. The taxpayers wanted to value the assets using projected cash flows, including the anticipated value of the grant itself as one of those cash flows, while the government wanted to use actual construction costs, plus a return for the developer.
• The Court of Federal Claims sided with cost, calling out the circular logic of a valuation method that uses the value of a tax credit to calculate the tax credit’s own basis.
• The case demonstrates that cost documentation beats theoretical valuation when building a basis claim. Contemporaneous, itemized construction costs — verified by a third party — carried far more weight with the court than a discounted cash flow model built years after the fact.
• For structuring going forward, developers should build the cost-segregation record at the time of transaction, get it audited by a credible third party, and support any developer-profit assumption with contemporaneous market comparables rather than a generic financial model.

What is the Alta Wind case?

Alta Wind has been in litigation for 13 years. Terra-Gen developed the six wind facilities in the Tehachapi Pass starting in 2008, but couldn’t collect the Section 1603 cash grant itself because some of its equity holders were tax-exempt — a disqualifying condition under the statute. To make the grant available at all, Terra-Gen sold the facilities to the plaintiffs in 2010–2012 through a mix of sale-leaseback and outright sale structures, and the plaintiffs applied for more than $703 million in grants based on their purchase prices. Treasury awarded roughly $495 million instead, calculated off construction costs rather than the full purchase price, and the plaintiffs sued for the shortfall.

A 2016 trial initially sided with the plaintiffs, awarding them approximately $206 million. The Federal Circuit vacated that judgment in 2018, holding that the purchase prices had to be allocated across the tax code’s asset-classification framework under Section 1060 rather than treated as a single lump sum, and it sent the case back for a new trial before a different judge — specifically instructing the court to separate “turn-key value” (the incremental value of a fully assembled, tested, working facility, which counts toward basis) from goodwill and other intangibles (which don’t). That retrial ran 11 days in mid-2025, drew testimony from four fact witnesses and five experts, and produced the 96-page opinion issued this July.

The core question: What actually counts as cost?

At issue was how to value six wind facilities in Tehachapi, California, for the purpose of calculating a 30% cash grant tied to the basis of the eligible property. The eligible basis is the total capitalized expenditure directly related to the acquisition, construction, and installation of a qualifying renewable energy property. ITCs are calculated as a percentage of the eligible basis of a qualifying clean energy project. For the six wind facilities involved in the litigation: 

• The taxpayers wanted to value the assets using projected cash flows — including the anticipated value of the grant itself as one of those cash flows. Roughly 98% of the anticipated grant value ended up in eligible basis under their model. 
• The government wanted to use actual construction costs, plus a return for the developer.

The court sided with cost. Developers and investors should pay attention to the reasoning behind the decision — courts don’t want a valuation method that uses the value of a tax credit to calculate the tax credit’s own basis. That’s circular, and the court called it out directly, noting the taxpayers offered no evidence that the market actually paid more for these assets because of the grant. Turbine prices, in fact, fell over the same period the grant was in effect — the opposite of what a “credit inflates asset value” theory would predict. 

Importantly, the income approach remains valid and relevant: the court did not hold that discounted cash flow (DCF) is inherently defective for these valuations — only that the record evidence here favored cost. A well-supported DCF remains a viable path to fair market value.

The takeaway for anyone building a basis claim: cost documentation beats theoretical valuation. Contemporaneous, itemized construction costs — verified by a third party — carried far more weight with the court than a discounted cash flow model built years after the fact.

What are the implications for development fees?

The court set developer profit at 15% for one facility and 20% for the other five. The government’s expert had proposed a single 9% rate for all six, derived from a capital asset pricing model. The court rejected that model because nothing tied that rate to what developers actually earn on wind projects.

Instead, the court leaned on third-party appraisals commissioned at the time of the original transactions. Those appraisals had set developer-profit ranges specific to each facility based on comparable wind projects: 10–15% for Alta I, 15–30% for Alta II–V, and 20% for Alta VI. For Alta I, the court capped profit at 15% — the top of that facility's appraised range and below the 20% the taxpayers sought. For the rest of the projects, the court adopted the taxpayers’ own proposed 20%.

The takeaway: developer profit needs a market anchor, not a formula. A rate supported by contemporaneous appraisals of comparable projects will hold up better than one derived from a generic cost-of-capital model with no connection to the specific facility. 

Notably, the court did not set a market ceiling: the contemporaneous appraisals in the record supported ranges as high as 30% for some facilities. The durable lesson is the evidentiary standard, not the level — a step-up supported by facility-specific comparables will hold up, wherever it lands.

What does this mean for basis positions going forward?

The court’s decision offers two durable takeaways for developers and tax credit investors structuring today’s deals:

1. Circularity is a real vulnerability. If a valuation approach treats the value of a tax benefit as an input into calculating that same benefit’s basis, expect that reasoning to draw the same scrutiny it drew here — regardless of which current-generation tax credit is involved.
2. Turn-key value has to be documented, not assumed. The court found the actual balance-of-plant and turbine-supply contracts already reflected the cost of delivering a fully integrated, tested facility, so no separate turn-key markup was warranted on top of those costs. Where a taxpayer wants to claim additional turn-key value, it needs its own evidentiary basis distinct from ordinary construction costs.

For structuring going forward, the practical implication is straightforward: build the cost-segregation record at the time of transaction, get it audited by a credible third party, and support any developer-profit assumption with contemporaneous market comparables rather than a generic financial model. 

What's next: Is this decision appealable?

The July 8 ruling isn’t a final judgment yet. It’s a trial order that directs the parties to file a joint status report by July 31 applying the court’s methodology to calculate the actual dollar figures owed — only after that report is filed will the court enter final judgment. That distinction matters for timing: the clock on any appeal doesn’t start until judgment is entered, not from this opinion’s issue date.

Once judgment is entered, either side can appeal to the US Court of Appeals for the Federal Circuit, which has exclusive jurisdiction over Court of Federal Claims appeals. Because the government is a party, the notice of appeal is due within 60 days of judgment. This case has already been through one full appeal cycle — the Federal Circuit vacated and remanded the 2016 trial verdict in 2018, which is why this retrial happened at all — so a second trip to the Federal Circuit is a real possibility, particularly given the size of the dollar amounts still in dispute and the fact that this opinion sets new methodology (the rejection of CAPM-derived developer profit, the treatment of Development Rights, and the circularity holding on cash grant value) that either side may want tested further.

Crux will track the joint status report and any subsequent appeal and will follow up as the final numbers and any appellate developments become public.

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